Heating for indirect boiling

ABSTRACT

Systems and methods relate to vaporizing water into steam, which may be utilized in applications such as bitumen production. The methods rely on indirect boiling of the water by contact with a substance such as solid particulate heated to a temperature sufficient to vaporize the water. Heating of the solid particulate may utilize pressure isolated heat exchanger units or a hot gas recirculation circuit at a pressure corresponding to that desired for the steam. Further, the water may form part of a mixture that contacts the solid particulate and includes a solvent for the bitumen in order to limit vaporization energy requirements and facilitate the production.

CROSS-REFERENCE TO RELATED APPLICATIONS

This application is a non-provisional application which claims benefit under 35 USC §119(e) to U.S. Provisional Application Ser. No. 61/737,973 filed Dec. 17, 2013, entitled “Heating for Indirect Boiling,” which is incorporated herein in its entirety.

STATEMENT REGARDING FEDERALLY SPONSORED RESEARCH OR DEVELOPMENT

None.

FIELD OF THE INVENTION

Embodiments of the invention relate to methods and systems for generating steam which may be utilized in applications such as bitumen production.

BACKGROUND OF THE INVENTION

Several techniques utilized to recover hydrocarbons in the form of bitumen from oil sands rely on generated steam to heat and lower viscosity of the hydrocarbons when the steam is injected into the oil sands. One common approach for this type of recovery includes steam assisted gravity drainage (SAGD). The hydrocarbons once heated become mobile enough for production along with the condensed steam, which is then recovered and recycled.

Costs associated with building a complex, large, sophisticated facility to process water and generate steam contributes to economic challenges of oil sands production operations. Such a facility represents much of the capital costs of these operations. Chemical and energy usage of the facility also contribute to operating costs.

Past approaches rely on once through steam generators (OTSGs) to produce the steam. However, boiler feed water to these steam generators requires expensive de-oiling and treatment to limit boiler fouling problems. Even with this treatment, fouling issues persist and are primarily dealt with through regular pigging of the boilers. This recurring maintenance further increases operating costs and results in a loss of steam production capacity, which translates to an equivalent reduction in bitumen extraction.

Therefore, a need exists for methods and systems for generating steam that enable efficient hydrocarbon recovery from a formation.

BRIEF SUMMARY OF THE DISCLOSURE

In one embodiment, a method of vaporizing water includes introducing a gaseous fluid into a first vessel and in contact with solid particulate within the first vessel to transfer heat from the gaseous fluid to the solid particulate. Upon recovering and then reheating the gaseous fluid from the first vessel, the gaseous fluid circulates back into the first vessel for continued heating of the solid particulate that is circulating between the first vessel and a second vessel. The water introduced into the second vessel contacts the solid particulate heated to a temperature that results in vaporizing the water into steam, which is then separated from the solid particulate.

For one embodiment, a system for vaporizing water includes a first vessel having an inlet and an outlet for a gaseous fluid and containing solid particulate in contact with the gaseous fluid that passes from the inlet to the outlet for transference of heat from the gaseous fluid to the solid particulate. A heater coupled to the inlet and the outlet of the first vessel reheats the gaseous fluid that is recovered from the outlet of the first vessel and circulated back to the inlet of the first vessel for sustained heating of the solid particulate. A second vessel couples to the first vessel by conduits through which the solid particulate is circulated between the first vessel and the second vessel. An injection line coupled to the second vessel supplies the water into the second vessel and in contact with the solid particulate heated to a temperature that results in vaporization of the water into steam. A steam output line coupled to the second vessel conveys the steam that is separated from the solid particulate.

BRIEF DESCRIPTION OF THE DRAWINGS

A more complete understanding of the present invention and benefits thereof may be acquired by referring to the following description taken in conjunction with the accompanying drawings.

FIG. 1 is a schematic of a steam generating system that includes dual vessels arranged to alternate between heating and steam generation cycles, according to one embodiment of the invention.

FIG. 2 is a schematic of a steam generating system with an exemplary heating vessel through which solid particulate circulates to regain thermal energy used to vaporize water, according to one embodiment of the invention.

FIG. 3 is a schematic of a steam generating system with a heating vessel in which heat is transferred to solid particulate via recycled gaseous fluid, according to one embodiment of the invention.

FIG. 4 is a schematic of a steam generating system with a heating vessel in which heat is transferred to solid particulate via recycled gaseous fluid that is condensed before reheating, according to one embodiment of the invention.

FIG. 5 is a schematic of a steam generating system with a heating vessel having an internal heat exchanger to transfer heat to solid particulate from hot fluids without direct contact, according to one embodiment of the invention.

FIG. 6 is a schematic of a steam generating system with a single vessel for vaporizing water upon contact with fluidized solid particulate disposed in the vessel and in thermal contact with a heat exchanger, according to one embodiment of the invention.

FIG. 7 is a schematic of the steam generating system shown in FIG. 3 and in a side-by-side vessel configuration, according to one embodiment of the invention.

DETAILED DESCRIPTION

Turning now to the detailed description of the preferred arrangement or arrangements of the present invention, it should be understood that the inventive features and concepts may be manifested in other arrangements and that the scope of the invention is not limited to the embodiments described or illustrated.

Embodiments of the invention relate to systems and methods for vaporizing water into steam, which may be utilized in applications such as bitumen production. The methods rely on indirect boiling of the water by contact with a substance such as solid particulate heated to a temperature sufficient to vaporize the water. Heating of the solid particulate may utilize pressure isolated heat exchanger units or a hot gas recirculation circuit at a pressure corresponding to that desired for the steam. Further, the water may form part of a mixture that contacts the solid particulate and includes a solvent for the bitumen in order to limit vaporization energy requirements and facilitate the production.

In any embodiments disclosed herein, the water may come from separated production fluid associated with a steam assisted gravity drainage (SAGD) bitumen recovery operation. The water at time of being generated into the steam may still contain: at least about 1000 parts per million (ppm), at least 10,000 ppm or at least 45,000 ppm total dissolved solids; at least 100 ppm, at least 500 ppm, at least 1000 ppm or at least 15,000 ppm organic compounds or organics; and at least 1000 ppm free oil. Injecting the steam through an injection well into the formation during the bitumen recovery operation thus enables sustainable recycle of the water without stringent treatment requirements of conventional boiler feed.

FIG. 1 illustrates a steam generating system that includes a first vessel 101 and a second vessel 102 that each contains solid particulate. As used herein, examples of the solid particulate include sand, metal spheres, cracking catalyst and mixtures thereof. In some embodiments, fluidization of the solid particulate keeps the solid particulate moving within the vessels 101, 102 during operation to generate steam. Such fluidization may involve circulation of the solid particulate and may rely on addition of supplemental steam.

Each of the vessels 101, 102 couples to a water injection line 104 and a heat source line 106. A manifold system controls flow through the vessels 101, 102 to a steam output 108 and an exhaust 110 and includes first through eighth valves 111-118. In operation, the valves 111-118 alternate between heating and steam generation cycles with the first vessel 101 being shown in the steam generation cycle while the second vessel 102 is in the heating cycle.

As shown, the first and fifth valves 111, 115 on the water injection line 104 and the steam output 108 thus remain open to flow of the water through the first vessel 101 to generate the steam while the third and seventh valves 113, 117 block flow of the water through the second vessel 102. The steam exits the first vessel 101 through the steam output 108, which may couple to the injection well, and is separated from the solid particulate that remains in the first vessel 101 and may be trapped by filters or cyclones. The second and sixth valves 112, 116 block flow from the heat source line 106 to the first vessel 101 at this time while the fourth and eighth valve 114, 118 are open to flow of oxygen and fuel, such as methane, from the heat source line 106 through the second vessel 102 to the exhaust 110. As thermal load of the solid particulate in the first vessel 101 becomes depleted, position of each of the valves 111-118 switches such that steam is generated in the second vessel 102 while the solid particulate is reheated in the first vessel 101.

The oxygen and fuel passing through the second vessel 102 combusts to reheat the solid particulate. During such combustion, contaminants, such as organic compounds deposited on the solid particulate from the water, may partially or fully convert into carbon dioxide and water, and some salts deposited on the solid particulate from the water may come off and be swept out of the second vessel 102. The combustion heats the solid particulate to a temperature that results in vaporizing the water upon contact therewith in the steam generation cycle that follows.

Not all embodiments rely on such cleaning of the solid particulate. Surface area of the solid particulate provides enough dispersion of the deposits to limit heat transfer interference. As needed over time, replacing some or part of the solid particulate may ensure desired performance is maintained at minimal cost and with limited to no interruption. For example, a lockhopper system employed with embodiments where the solid particulate is always in a pressurized environment can enable such withdrawal and replacement while in continuous operation.

Due to the first and second vessels 101, 102 with the manifold system, the heat source line 106 can supply the oxygen and fuel without compression to pressures desired for the steam to be injected into the formation. This relative lower pressure combustion facilitates economic production of the steam. Alternating each of the vessels 101, 102 between the steam generation cycle and the heating cycle also eliminates need for conveying the solid particulate to units dedicated to one particular cycle.

In some embodiments, the water mixes with a solvent 120 for the bitumen prior to vaporization due to contact with the solid particulate. The solvent 120 (common reference number depicted in all figures) thus may flow as a liquid into the water supply line 104 to form a resulting mixture of the water with the solvent 120. Vaporization of the water along with the solvent 120 results in the steam output 108 also containing both water and solvent vapors, as may be desired for injection into the formation.

The solvent 120 may include hydrocarbons having between 3 and 30 carbon atoms, such as butane, pentane, naphtha and diesel. Temperatures associated with the indirect boiling described herein limit potential problems of cracking the hydrocarbons, which can tend to occur if passed through direct fired boilers that may thus require injection of any wanted solvents into steam rather than boiler feed. Such injection of the solvent into the steam instead of the water feed may either cause loss of some steam due to condensation or require superheating of the steam. Conventional superheating of the steam also suffers from fouling problems. Therefore, the solvent 120 may flow into steam superheated by steam generation methods described herein in some embodiments since the fouling issues from the superheating are overcome in the same manner as those associated with steam generation.

The mixture in the water supply line 104 may include between 5 and 30 percent of the liquid hydrocarbon by volume. The mixture may further provide an energy requirement for vaporization that is at least 10 percent lower than water alone. For example, a 28:72 ratio of butane to water reduces steam generator duty by 22 percent as compared to water alone.

FIG. 2 shows a steam generating system with a steam generating riser 200 and/or vessel 201 and a heating vessel 202 through which solid particulate are circulated. Similar to the system in FIG. 1, a heat source line 206 supplies reactants for combustion within the heating vessel 202 in order regain thermal energy used to vaporize water. Flue gases from the combustion exit the heating vessel 202 through exhaust 210 following any filtering to retain the solid particulate. Multiple alternating heating vessels with flow control similar to FIG. 1 or lockhoppers may enable operation of the heating vessel 202 at a lower pressure than the steam generating riser 200 and/or vessel 201.

In some embodiments, the solid particulate heated in the heating vessel 202 transfers to the steam generating vessel 201 by gravity since the heating vessel 202 is disposed above the steam generating vessel 201. A water supply line 204 then inputs the water into contact with the solid particulate that is heated to result in vaporizing the water and providing a steam output 208. Some of the steam output 208 may provide lift for the solid particulate being returned up the riser 200 to the heating vessel 202. For some embodiments, the water vaporizes in the riser 200 such that the steam generating vessel 201 is not even required and the steam is recovered at a riser output 209.

FIG. 3 illustrates a steam generating system with a heating vessel 302 in which heat is transferred to solid particulate via recycled gaseous fluid circulating in a circuit. Similar to systems in other figures, the solid particulate once heated transfers to a steam generating vessel 301 where water 304 is input to contact the solid particulate and generate steam 308. Embodiments may therefore implement various features and attributes explained in detail with respect to another particular figure or elsewhere herein without being repeated in order to be as succinct as possible.

The gaseous fluid that exits the heating vessel 302 through an outlet 310 passes through heat exchanger(s) 350 and a fin-fan cooler 352, if necessary. The heat exchanger 350 may transfer heat with the gaseous fluid post compression boosting and/or with the water 304 being input into the steam generating vessel 301. Such heat exchange helps maintain efficiency while bringing the temperature of the gaseous fluid below temperature limits of a compressor 358 through which the gaseous fluid is sent downstream in the circuit.

A purge 354 allows removal of a portion of the gaseous fluid, which may pick up contaminants, such as from cracking or entrainment. Makeup gas 356 combines with the gaseous fluid to replace that purged. In some embodiments, the gaseous fluid includes an inert gas such as nitrogen and may also include air or oxygen for burning of the deposits. Methane may provide the gaseous fluid for some embodiments and may be desired due to its relative higher thermal capacity.

The compressor 358 only boosts pressure of the gaseous fluid circulating through the circuit. For example, the compressor may provide between 50 and 150 kilopascals (kPa) boost in pressure, which is achievable without making steam generation uneconomical by requiring levels of compression needed to increase atmospheric pressure to above 2500 kPa. The gaseous fluid in the circuit may thus always remain above 2500 kPa, in some embodiments.

The gaseous fluid from the compressor 358 then flows through the circuit to a furnace 360. The furnace 360 burns fuel to reheat the gaseous fluid that reenters the heating vessel 302 through a heat source line 306 for sustained heating of the solid particulate within the heating vessel 302. The heating vessel 302 may include multiple (e.g., 6 as shown) bed stages 362 or trays such that the solid particulate passing through the heating vessel 302 counter current with the gaseous fluid achieves efficient heat cross exchange.

Pressure of the steam desired for injection into the formation dictates pressure inside the steam generating vessel 301. With the recycled gaseous fluid circulating in the circuit to reheat the solid particulate, both the steam generating vessel 301 and the heating vessel 302 may operate at this pressure, such as above 2500 kPa, provided there may be sufficient differences in pressure in the vessels 301, 302 or other such arrangements described herein to maintain fluid flows. For some embodiments, a slipstream 364 of the gaseous fluid also at necessary pressure provides lift for transporting the solid particulate from the steam generating vessel 301 to the heating vessel 302.

FIG. 4 shows a steam generating system with a heating vessel 402 in which heat is transferred to solid particulate via recycled gaseous fluid that is circulating in a circuit and condensed before reheating. While shown as being recycled, the gaseous fluid in some embodiments passes once through the vessel 402 and may then be utilized in another application. Like the system in FIG. 3, the solid particulate once heated transfers to a steam generating vessel 401 where water 404 is input to contact the solid particulate and generate steam 408. The gaseous fluid that exits the heating vessel 402 through an outlet 410 passes through heat exchanger(s) 450 that transfer heat from flow along the circuit post pumping and/or with the water 404 being input into the steam generating vessel 401. The heat exchange 450 condenses the gaseous fluid, such as propane, butane or naphtha, to a liquid phase for pressurization by a pump 458. Before the pump 458, a separator 454 may enable venting off gasses that are not condensed, such as may result from cracking of the gaseous fluid.

Outflow from the pump 458 and any makeup 456 then flows through the circuit to a furnace 460. The furnace 460 burns fuel to vaporize and reheat the gaseous fluid that reenters the heating vessel 402 through a heat source line 406 for sustained heating of the solid particulate within the heating vessel 402. While pressure in the circuit again stays at a level similar to that desired for the steam to be injected into the formation, the pump 458 may influence efficiency if used in place of compression. Use of the pump 458 with the gaseous fluid that is condensed may further enable economic once through heating (i.e., without the circuit) at the desired pressure similar to approaches depicted in FIG. 1 or 2 (i.e. replace oxygen and methane for combustion with a higher hydrocarbon pumped and then heated as in FIG. 4) except that resulting exhaust may have further application for its energy content.

FIG. 5 illustrates a steam generating system with a heating vessel 502 having an internal heat exchanger 562 to transfer heat to solid particulate from hot fluids without direct contact. Similar again to systems in other figures, the solid particulate once heated transfers to a steam generating vessel 501 where water 504 is input to contact the solid particulate and generate steam 508. Both the steam generating vessel 501 and the heating vessel 502 may operate in open pressure communication with one another at an internal pressure desired for injection of the steam into a formation while pressure isolated flow through the heat exchanger 562 may be at a lower pressure.

In operation, oxygen and fuel react in a combustor 560 to generate a flue gas conveyed to the heat exchanger 562 by a heat source line 506. The flue gas passes through the heat exchanger 562 and exits via an exhaust 510. A thermally conductive material forms the heat exchanger 562 such that heat from the flue gas transfers to the solid particulate in the heating vessel 502. In some embodiments, the thermally conductive material forms a tube of the heat exchanger. The tube may coil within the heating vessel 510 to provide the heat exchanger 562 with either the solid particulate flowing through an inside of the tube or the flue gas flowing through the inside of the tube.

For some embodiments, a fluidization gas, such as air, passes through the inside of the heating vessel 502. This gas may help remove contaminants from the solid particulate as well. Use of the gas for only fluidization while relying on heating by the heat exchanger 562 limits quantity and compression requirements for the gas whether the gas is used once through or circulated in a circuit.

FIG. 6 shows a steam generating system with a single vessel 600 for vaporizing water upon contact with fluidized solid particulate disposed in the single vessel 600 and in thermal contact with a heat exchanger 662. The solid particulate heated by the heat exchanger 662 contacts water 604 that is input into the single vessel to generate steam 608. In operation, a circulating liquid, such as sodium or sodium and potassium, passes through the heat exchanger 662, exits the heat exchanger via an outlet 610 and is pumped by an pump 658 to a furnace 660 that reheats the circulating liquid prior flowing back to the heat exchanger 662 via inlet 606.

The heat exchanger 662 transfers heat from the circulating liquid to the solid particulate and may have a design such as described with respect to the heat exchanger 562 shown in FIG. 5. Vaporization of the water 604 still occurs upon contacting the solid particulate that is heated. While the solid particulate thus should receive deposits from the water 604, movement of the solid particulate along the heat exchanger 662 provides abrasion to ensure that the heat exchanger 662 does not become fouled.

The heat exchangers 562, 662 in FIGS. 5 and 6 may each operate with either the flue gas or the circulating liquid as described herein providing hot fluid thereto. In some embodiments, systems may incorporate both the heat exchanger 662 where the steam is being generated along with additional heating of the solid particulate such as provided in the heating vessel 302 shown in FIG. 3. Sharing this thermal load may enable efficient operation.

FIG. 7 shows the system illustrated in FIG. 3 with the steam generating vessel 301 disposed at a common elevation with the heating vessel 302 as opposed to a stacked vertical arrangement. This side-by-side configuration limits or eliminates need to use lift gas for transfer of the solid particulate. The solid particulate transfers between the steam generating vessel 301 and the heating vessel 302 via dense phase gravity drain as a result of such at least partial overlapping height. As shown, an upper outlet of the steam generating vessel 301 couples to a relative lower inlet of the heating vessel 302 for flow from the steam generating vessel 301 to the heating vessel 302. In a similar manner, a bottom outlet of the heating vessel 302 couples to a relative lower inlet of the steam generating vessel 301 for flow from the heating vessel 302 to the steam generating vessel 301.

Overall volumetric gas flow rate reduces as demand for the lift gas decreases. This flow rate reduction enables utilizing smaller recycle power requirement of the compressor 358 and cross exchanger surface area defined by the heating vessel 302, which both lower costs. Further, these benefits may facilitate selection of the gaseous fluid that otherwise may lack suitable thermal properties for heating the solid particulate.

Although the systems and processes described herein have been described in detail, it should be understood that various changes, substitutions, and alterations can be made without departing from the spirit and scope of the invention as defined by the following claims. Those skilled in the art may be able to study the preferred embodiments and identify other ways to practice the invention that are not exactly as described herein. It is the intent of the inventors that variations and equivalents of the invention are within the scope of the claims, while the description, abstract and drawings are not to be used to limit the scope of the invention. Each and every claim below is hereby incorporated into this detailed description or specification as additional embodiments of the present invention. The invention is specifically intended to be as broad as the claims below and their equivalents. 

1. A method of vaporizing water, comprising: introducing a gaseous fluid into a first vessel and in contact with solid particulate within the first vessel to transfer heat from the gaseous fluid to the solid particulate; recovering the gaseous fluid from the first vessel; reheating the gaseous fluid recovered from the first vessel prior to circulating the gaseous fluid back into the first vessel for continued heating of the solid particulate; circulating the solid particulate between the first vessel and a second vessel; introducing the water into the second vessel and in contact with the solid particulate heated to a temperature that results in vaporizing the water into steam; and separating the steam from the solid particulate.
 2. The method according to claim 1, wherein the gaseous fluid includes at least one of nitrogen, methane, propane, butane, naphtha and oxygen.
 3. The method according to claim 1, wherein the first and second vessel are maintained at pressures above 2500 kilopascals.
 4. The method according to claim 1, wherein the gaseous fluid recovered from the first vessel is condensed into a liquid and pumped for pressurization prior to being reheated.
 5. The method according to claim 1, wherein the gaseous fluid includes oxygen such that the reheating burns off organics from the water that are deposited on the solid particulate.
 6. The method according to claim 1, wherein the first vessel is disposed beside the second vessel and the solid particulate transfers between the first vessel and the second vessel by dense phase gravity drain.
 7. The method according to claim 1, wherein at least part of the gaseous fluid is directed to provide lift for transporting the solid particulate between the first and second vessels.
 8. The method according to claim 1, wherein the first vessel includes multiple bed stages that the solid particulate passes through countercurrent with the gaseous fluid.
 9. The method according to claim 1, further comprising also heating the solid particulate in the second vessel by heat exchange with hot fluids separated from the solid particulate by a thermally conductive material.
 10. The method according to claim 1, wherein a riser forms the second vessel.
 11. A system for vaporizing water, comprising: a first vessel having an inlet and an outlet for a gaseous fluid and containing solid particulate in contact with the gaseous fluid that passes from the inlet to the outlet for transference of heat from the gaseous fluid to the solid particulate; a heater coupled to the inlet and the outlet of the first vessel for reheating the gaseous fluid that is recovered from the outlet of the first vessel and circulated back to the inlet of the first vessel for sustained heating of the solid particulate; a second vessel coupled to the first vessel by conduits through which the solid particulate is circulated between the first vessel and the second vessel; an injection line coupled to the second vessel to supply the water into the second vessel and in contact with the solid particulate heated to a temperature that results in vaporization of the water into steam; and a steam output line coupled to the second vessel for conveying the steam that is separated from the solid particulate.
 12. The system according to claim 11, wherein the gaseous fluid includes at least one of nitrogen, methane, propane, butane, naphtha and oxygen.
 13. The system according to claim 11, wherein the first and second vessel are at pressures above 2500 kilopascals.
 14. The system according to claim 11, further comprising a condenser and pump coupled together such that the gaseous fluid recovered from the first vessel is condensed into a liquid and pumped to a preset pressure prior to being reheated.
 15. The system according to claim 11, wherein the gaseous fluid includes oxygen to burn off organics from the water that are deposited on the solid particulate.
 16. The system according to claim 11, further comprising a bypass for at least part of the gaseous fluid to provide lift for transporting the solid particulate between the first and second vessels.
 17. The system according to claim 11, wherein the first vessel is disposed above the second vessel such that the solid particulate transfers from the first vessel to the second vessel by gravity.
 18. The system according to claim 11, wherein the first vessel includes multiple bed stages that the solid particulate passes through countercurrent with the gaseous fluid.
 19. The system according to claim 11, further comprising a heat exchanger disposed in the second vessel that also heats the solid particulate by heat transfer with hot fluids separated from the solid particulate by thermally conductive material of the heat exchanger.
 20. The system according to claim 11, wherein a riser forms the second vessel. 